Obtaining a downhole core sample measurement using logging while coring

ABSTRACT

A drilling tool and method are disclosed for obtaining a downhole core sample measurement using logging while coring. A drilling tool includes a coring bit that is configured to obtain a core sample from a wellbore. A coring mandrel is coupled to the coring bit and includes an inner gage bore. An inner barrel is disposed inside the inner gage bore and an inner sleeve configured to receive the core sample is disposed inside the inner barrel. Coring bit electronics are coupled to the coring mandrel.

TECHNICAL FIELD

The present disclosure relates generally to coring operations ofdownhole drilling and, more particularly, to a drilling tool and methodfor obtaining a downhole core sample measurement using logging whilecoring.

BACKGROUND

Conventional logging techniques, such as wireline and logging whiledrilling (LWD), employ tools that use dedicated sensors to collect datafrom the surrounding formation of a wellbore. The signal between thetransmitters and receivers passes through a very complicated and openenvironment that is susceptible to noise, multipath propagation,washout, mud cake, and invasion problems. These borehole conditions addtremendously to the cost and complexity of the tool, and affect itsreading accuracy. Along with the inherent geometrical layout of thetool, this puts a limit on the class of measurements/sensors that can beused, the data acquisition resolution, and the direction of measurement

Conventional tools for obtaining a core from the bitface at the end of awellbore use dedicated coring drill bits to collect cylindrical coresamples. Core samples are subsequently inspected and analyzed at thesurface by various equipment and techniques depending on the type ofinformation to be collected. For example, core samples can provideindications of formation properties such as porosity, permeability, andother physical or petrophysical properties of the downhole formation.

In typical operations, a coring drill bit may be used to collect acontinuous core sample at the bitface during the drilling operation.Multiple core samples may be collected and stored in proximity to thecoring drill bit. After collection of the desired number of samples, thecore samples are lifted to the surface to measure properties of thesamples. Most laboratories extract only small plugs from the coresamples and provide a relatively small number of data points across thewhole well.

The core samples, however, can be damaged or compromised in the processof lifting the core samples to the surface. Thus, conventional systemstypically include components to support and protect the core samplewhile lifting it to the surface. Contact between drilling fluids and thecore sample may compromise later measurements made to the core sample.Furthermore, mechanical forces during removal and lifting of the coresample may cause the core sample to fracture, which may complicate theability to gather information from the core sample. Core samples canfurther degrade when they are transported to a laboratory, or otherwisehandled to study. Incorrect or inconsistent values from core samples mayhave severe implications for wellbore drilling operations.

BRIEF DESCRIPTION OF THE DRAWINGS

For a more complete understanding of the present disclosure and itsfeatures and advantages, reference is now made to the followingdescription, taken in conjunction with the accompanying drawings, inwhich:

FIG. 1 illustrates a schematic diagram of a drilling apparatus for alogging while drilling or a coring tool in a wellbore, in accordancewith some embodiments of the present disclosure;

FIG. 2 illustrates a perspective view of a coring bit assembly, inaccordance with some embodiments of the present disclosure;

FIG. 3 illustrates a perspective view of coring bit electronicsassociated with a coring bit assembly for performing measurementstransversely across a core sample, in accordance with some embodimentsof the present disclosure;

FIG. 4 illustrates a cross-sectional view of the coring bit electronicsin the coring bit assembly of FIG. 3 for performing measurementstransversely across a core sample, in accordance with some embodimentsof the present disclosure;

FIG. 5 illustrates a cross-sectional view of coring bit electronics in acoring bit assembly for performing measurements to detect anisotropicproperties across a core sample, in accordance with some embodiments ofthe present disclosure;

FIG. 6 illustrates a perspective view of coring bit electronics in acoring bit assembly for performing measurements transversely andlongitudinally across a core sample, in accordance with some embodimentsof the present disclosure; and

FIG. 7 illustrates a flow chart of an example method for performingmeasurements on a core sample during LWC operation with coring bitelectronics, in accordance with some embodiments of the presentdisclosure.

DETAILED DESCRIPTION

Embodiments of the present disclosure and its advantages are bestunderstood by referring to FIGS. 1-7, where like numbers are used toindicate like and corresponding parts.

FIG. 1 illustrates a schematic diagram of a drilling apparatus 100 for alogging while drilling or a coring tool in wellbore 106, in accordancewith some embodiments of the present disclosure. Drilling tool 116 maybe suspended by drill pipe 104 in wellbore 106 defined by sidewall 108.

Drill pipe 104 may include one or more electrical conductors and amulti-strand cable. Drill pipe 104 may include an armored logging cableand may encompassing the cables and conductors. In some embodiments,drill pipe 104 may include drilling tool 116 and may be extended intowellbore 106.

In some embodiments, drilling tool 116 may include any device orcombination of devices suitable for drilling wellbore 106 and/orextracting core samples from wellbore 106. Drilling tool 116 may rotateby the operation of drill pipe 104 to extract a core sample or drillinto wellbore 106.

In some embodiments, logging while drilling (LWD) may include drillinginto the earth and recording information from sensors 120 that may belocated proximate the exterior of drilling tool 116 above the drill bitor coring bit 102 to produce a record of various formation parameters.In such configurations, drilling tool 116 may include coring bitassembly 126, drill collar 118, sensors 120, other on-board electronics,telemetry systems, pressure compensators, hydraulic fluid systems,and/or any other suitable devices. Drill collar 118 and sensors 120 maybe located above coring bit 102 with respect to drill pipe 104. Drillcollar 118 may include electronics that measure sensor 120 outputs andstore them as a function of time or transmit them to a surface controlunit and/or any other suitable compute. Sensors 120 may providecontinuous measurements of downhole parameters, such as, porosity,resistivity, formation pressure, and/or any other suitable measurements.Sensors 120 may be located on the exterior of drilling tool 116 and maybe configured to detect downhole parameters as drilling tool 116descends and/or drills into wellbore 106. However, due to the locationof sensors 120, e.g., above coring bit 102 with reference to drill pipe104, sensors 120 may provide indirect measurements of the currentformation being drilled and may be affected by the downhole environment.For example, sensors 120 may be exposed to mud as mud flows pastdrilling tool 116. Accuracy of sensors 120 may additionally be affectedby standoff between drilling tool 116 and sidewall 108. Further, thedirection of sensors 120 with respect to sidewall 108 may be orientedsuch that the direction may also affect accuracy of measurements.

In some embodiments, alternate configurations of drilling apparatus 100may be arranged for Logging While Coring (LWC) operations. LWC mayinclude extracting a core sample and detecting and/or recordinginformation from sensors that may be located proximate to the interiorof drilling tool 116. In such embodiments, LWC may include taking, e.g.logging, measurements of a core sample as the core sample is passingthrough drilling tool 116. In LWC operation, coring bit assembly 126(shown in further detail in FIG. 2) may include coring bit 102 and mayoperate to extract a core sample from wellbore 106. In some embodiments,coring bit assembly 126 may also include sensors, calipers, electronics,transmitters, receivers, and other elements to perform in-situmeasurements of a core sample. As discussed below, the measurements maybe transmitted to a surface control unit, drill collar 118, and/or othersuitable devices for further analysis. The sensors may continuouslycollect data from a moving string of cores in critical spots of thewell. LWC operation may improve measurement accuracy and resolution, addanisotropic capabilities, and introduce new classes of measurements thatmay not be achievable with LWD operation.

FIG. 2 illustrates a perspective view of coring bit assembly 126, inaccordance with some embodiments of the present disclosure. Coring bit102 may be any of various types of fixed cutter drill bits, includingpolycrystalline diamond cutter (PDC) bits, drag bits, matrix drill bits,and/or steel body drill bits operable to extract a core sample fromwellbore 106. Coring bit 102 may be designed and formed in accordancewith teachings of the present disclosure and may have many differentdesigns, configurations, and/or dimensions according to the particularapplication of coring bit 102.

Coring bit body 306 may have a generally cylindrical body and inner gage314. Coring bit 102 may further include throat 310 that may extendlongitudinally through coring bit 102. Throat 310 of coring bit 102 mayallow a core sample to be cut with a smaller diameter than throat 310.Coring bit 102 may include one or more cutting elements 302 disposedoutwardly from exterior portions of bit body 306. For example, a portionof cutting element 302 may be directly or indirectly coupled to anexterior portion of bit body 306 while another portion of cuttingelement 302 may be projected away from the exterior portion of bit body306. Cutting elements 302 may be any suitable device configured to cutinto a formation, including but not limited to, primary cuttingelements, back-up cutting elements, secondary cutting elements or anycombination thereof. By way of example and not limitation, cuttingelements 302 may be various types of cutters, compacts, buttons,inserts, and gage cutters satisfactory for use with a wide variety ofcoring bits 102.

Cutting elements 302 may include respective substrates with a layer ofhard cutting material disposed on one end of each respective substrate.The hard layer of cutting elements 302 may provide a cutting surfacethat may engage adjacent portions of wellbore 106. Each substrate ofcutting elements 202 may have various configurations and may be formedfrom tungsten carbide or other materials associated with forming cuttingelements for coring bits. Tungsten carbides may include, but are notlimited to, monotungsten carbide (WC), ditungsten carbide (W₂C),macrocrystalline tungsten carbide and cemented or sintered tungstencarbide. Substrates may also be formed using other hard materials, whichmay include various metal alloys and cements such as metal borides,metal carbides, metal oxides and metal nitrides. For some applications,the hard cutting layer may be formed from substantially the samematerials as the substrate. In other applications, the hard cuttinglayer may be formed from different materials than the substrate.Examples of materials used to form hard cutting layers may includepolycrystalline diamond materials, including synthetic polycrystallinediamonds.

In operation of embodiments of the present disclosure, coring bit 102may extract a core sample from a formation of interest approximately thediameter of throat 310. As discussed in detail below, sensors, calipers,electronics, and other elements resident in coring bit assembly 126 maymake in-situ measurements of the core sample.

Coring bit 102 may be connected to coring mandrel 402. Coring mandrel402 may have a longitudinal opening 404 that may correspond to throat310. One end of coring mandrel 402 may be threadably connected tothreaded form 406 Inner barrel 408 may pass through coring mandrel 402and/or threaded form 406. Further, inner barrel 408 may contain innersleeve 410 that may capture core sample 412. Inner sleeve 410 may beencompassed by inner barrel 408 and/or may extend beyond inner barrel408. Threaded form 406 may connect inner barrel 408 to coring bit 102via coring mandrel 402.

Additionally, in some embodiments of the present disclosure coring bitelectronics 414 may be contained in coring mandrel 402. Coring bitelectronics 414 may also be located in inner barrel 408 (not expresslyshown), inner sleeve 410 (not expressly shown), and/or any combinationof coring mandrel 402, inner barrel 408, and inner sleeve 410, and/orany other suitable location. Coring bit electronics 414 may include anyreceivers, transmitters, transceivers, sensors, calipers, and/or otherelectronic components that may be used in a downhole measurement system.Sensors may include multiple types, including but not limited to,resistivity, dielectric, sonic, nuclear, or nuclear magnetic resonance(NMR). Coring bit electronics 414 may also include any necessaryelectronics to provide communication between the receivers,transmitters, transceivers, sensors, calipers, and/or other electroniccomponents. The spacing, exact location, and transmitter-receiverarrangement of coring bit electronics 414 may depend on factorsincluding, but not limited to, the direction of measurement and/or thetype of sensors, calipers, and/or other types of measurement tools.

Implanting coring bit electronics 414 in coring mandrel 402, innerbarrel 408, inner sleeve 410, and/or any other suitable location mayallow coring bit electronics 414 to perform direct and/or continuousmeasurements as core sample 412 moves through coring bit assembly 126.Accordingly, some embodiments of the present disclosure may allowmeasurements of core sample 412 to be made in drilling tool 116 (asshown with reference to FIG. 1). Following extraction from wellbore 106,core sample 412 may be stored and later retrieved and lifted to thesurface. Core sample 412 may be lifted to the surface by retrievinginner sleeve 410 and/or by extraction of drilling tool 116 from wellbore106.

During LWD operation, contamination may affect measurements made bysensors 120 due to characteristics of the wellbore environment,including tool standoff, washouts, mud flows and/or other situationsthat may compromise measurement integrity of sensors 120. Similarconditions may apply during wireline operations, which may includelowering sensors into a wellbore after removal of a drilling tool.However, during LWC operation the measurements made by coring bitelectronics 414 of a core sample may not be affected by such wellboresituations. Measurements by coring bit electronics 414 may have theadvantage of a measurement environment confined around core sample 412being relatively small. The distance between multiple sensors and/orother elements may also be relatively small in the confined environmentof coring bit assembly 126. Noise and multi-path effects that may bepresent in the wellbore and may affect measurements made by sensors 120may not be present around coring bit electronics 414 during LWCoperation. Therefore, coring bit electronics 414 may be simpler inconfiguration and design than sensors 120. For example, the confinedspace may minimize the transverse movement of core sample 412 in coringmandrel 402, inner barrel 408, and/or inner sleeve 410 allowing for lesseccentricity related impact and more consistent measurements.Additionally, the power requirements for coring bit electronics 414 maybe less than the power requirements for sensors 120. Further, asdiscussed in detail below with reference to FIGS. 5 and 6, LWC operationutilizing coring bit electronics 414 may include measuring parameters ofcore sample 412 in multiple directions, e.g., x-axis, y-axis, andz-axis. Resolution of measurements may also be improved since resolutionmay be a function of the distance between sensors. LWC operationutilizing coring bit electronics 414 may provide a minimum distancebetween a transmitter and a receiver, and thus, may provide enhancementsto resolution than may be achieved with LWD.

Additionally, when compared with the conventional logging methods (e.g.,wireline and LWD), LWC may provide real-time formation measurements thatmay have better correlation with the core laboratories measurements. LWCmay further overcome issues regarding core porosity and mechanicalproperties that may occur after a core sample is removed from thewellbore to a laboratory for measurement.

The LWC tool may be operated as the sole logging tool or in conjunctionwith other logging techniques. This may be done in order to obtainincreasingly accurate, high-resolution and anisotropic data in thecritical spots of the wellbore. The collected data may also be used tocalibrate readings from LWD or wireline sensors outside the cored rangeto enhance their accuracy without the need to wait for laboratory data.

FIG. 3 illustrates a perspective view of the coring bit electronics in acoring bit assembly for performing measurements transversely across acore sample, in accordance with some embodiments of the presentdisclosure. In the illustrated embodiment, a portion of coring mandrel402 containing a portion of core sample 412 is shown. Coring mandrel402, inner barrel 408, inner sleeve 410 (shown in FIG. 2), and/or anyother suitable location may include coring bit electronics 414. Coringbit electronics 414 may include transmitter 502, receiver 504, sensors,calipers, and/or other electronics or elements suitable for measurementof core sample 412. This configuration may allow the measurement ofproperties across core sample 412 in the transverse direction, e.g., thex-axis direction. Additionally, some embodiments of the presentdisclosure may include receiver 504 without transmitter 502.

In some embodiments, during LWC operation, coring bit 102 may extractcore sample 412 from the formation. Core sample 412 may be captured byinner sleeve 410 and pass through inner barrel 408. As the core sample412 passes through inner barrel 408, coring bit electronics in coringmandrel 402 may make measurements of various characteristics andproperties of core sample 412, for example. The measurements may betaken continuously as core sample 412 passes through coring bitassembly, and/or the measurements may be interval based and may beprogrammed to take a measurement based on either elapsed time and/orlength of core sample 412. Additionally, the measurements may be takenas needed based on a pre-defined measurement protocol.

In some embodiments, measurements made by coring bit electronics 414 maybe communicated to a surface control unit and/or any other suitable unitfor receiving signals from coring bit electronics 414. Logs may becreated using information from coring bit electronics 414 and the logsmay exhibit improved accuracy than would be achieved by sensors 120 orachieved after core sample 412 is removed to the surface. Further,additional classes of measurements, e.g., computed tomography and/orother scanning techniques may be available to coring bit assembly 126,in accordance with some embodiments of the present disclosure.

FIG. 4 illustrates a cross-sectional view of coring bit electronics 414in coring bit assembly 126 of FIG. 3 for performing measurementstransversely across a core sample, in accordance with some embodimentsof the present disclosure. Transmitter 502 and/or receiver 504 may bemounted within or attached to coring mandrel 402. Although the presentembodiment is illustrated with respect to coring mandrel 402,transmitter 502 and/or receiver 504 may also and/or alternatively bemounted within or attached to inner barrel 408, inner sleeve 410, and/ormounted in any suitable location. Transmitter 502 may be locatedsubstantially opposite from receiver 504 with respect to core sample412. Sensors, calipers, and/or other measurement tools may be includedas part of or near to transmitters 502 and/or receivers 504. Further,transmitter 502 and/or receiver 504 may be transceivers in order totransmit and receive from both sides of coring mandrel 402, inner barrel408, and/or inner sleeve 410. In operation of embodiments of the presentdisclosure, a signal may be sent from transmitter 502 and received byreceiver 504. The characteristics and properties of the signal receivedby receiver 504 may indicate various properties of core sample 412,e.g., porosity, permeability, and other physical or petrophysicalproperties of core sample 412. The resultant signals and/or measurementsmay be communicated to a surface control unit via any suitable methodfor communicating data.

FIG. 5 illustrates a cross-sectional view of coring bit electronics 414in coring bit assembly 126 for performing measurements to detectanisotropic properties across core sample 412, in accordance with someembodiments of the present disclosure. In the illustrated embodiment,coring bit electronics 414 may contain two transmitters 502 a and 502 band two receivers 504 a and 504 b. Transmitter 502 a may be arrangedsubstantially opposite from receiver 504 a with respect to core sample412, e.g., along the x-axis. Likewise, transmitter 502 a may be arrangedsubstantially opposite from receiver 504 b with respect to core sample412 and approximately ninety degrees rotated from transmitter 502 a andreceiver 504 a, e.g., along the y-axis. Sensors, calipers, and/or othermeasurement tools may be included as part of or near to transmitters 502and/or receivers 504. Further, transmitters 502 and/or receivers 504 maybe transceivers in order to transmit and receive from both sides ofcoring mandrel 402 and/or inner barrel 408. In operation of embodimentsof the present disclosure, a signal may be sent from transmitter 502 aand received by receiver 504 a. Additionally, a signal may be sent fromtransmitter 502 b and received by receiver 504 b. The characteristicsand properties of the signal received by receivers 404 may indicatevarious properties of core sample 412, e.g., porosity, permeability,and/or other physical or petrophysical properties of core sample 412.The resultant signals and/or measurements may be communicated to asurface control unit via any suitable method for communicating data. Theconfiguration shown in FIG. 5 may allow the detection of anisotropicproperties in core sample 412 (e.g., detection of unequal physicalproperties along different axes) by measuring core sample 412 propertiesin both the x-axis and y-axis directions.

FIG. 6 illustrates a perspective view for coring bit electronics 414 incoring bit assembly 126 for performing measurements transversely andlongitudinally across core sample 412, in accordance with someembodiments of the present disclosure. Transmitters 502 and/or receivers504 may be mounted within or attached to coring mandrel 402. Althoughthe present embodiment is illustrated with respect to coring mandrel402, transmitters 502 and/or receivers 504 may also and/or alternativelybe mounted within or attached to inner barrel 408, inner sleeve 410,and/or mounted in any suitable location. In the illustrated embodiment,coring bit electronics 414 may include two receivers 504 a and 504 b andtransmitter 502 a. Transmitter 502 a may be arranged substantiallyopposite from receiver 504 a with respect to core sample 412, e.g.,along the x-axis. Receiver 504 b may be arranged axially withtransmitter 502 b, e.g., along the z-axis. Sensors, calipers, and/orother measurement tools may be included as part of or near totransmitter 502 a and/or receivers 504 a and 504 b. Further, transmitter502 a and/or receivers 504 a and 504 b may be transceivers in order totransmit and receive from both sides of coring mandrel 402, inner barrel408, and/or inner sleeve 410. In operation of embodiments of the presentdisclosure, a signal may be sent from transmitter 502 a and received byreceiver 504 a and/or receiver 504 b. The characteristics and propertiesof the signal received by receivers 504 may indicate various propertiesof core sample 412, e.g., porosity, permeability, and/or other physicalor petrophysical properties of core sample 412. The resultant signalsand/or measurements may be communicated to a surface control unit viaany suitable method for communicating data. The configuration shown inFIG. 6 may allow both transverse measurement (e.g., between transmitter502 a and receiver 504 a) and longitudinal measurement (e.g., betweentransmitter 502 a and receiver 504 b).

As exemplified by FIGS. 2-6, many arrangements may exist for coring bitelectronics 414 to enable different types of measurements of core sample412. Other suitable configurations of components may be used as part ofthe coring bit electronics without departing from the scope of thepresent disclosure. For example, coring bit electronics 414 may includemore or fewer components, including transmitters 502 and receivers 504,than shown in FIGS. 2-6. As another example, coring bit electronics 414may allow for measurements based on electromagnetic radiation or a lightspectrum, such as visible light, infra-red, ultraviolet, and/or x-ray.In designing a configuration in embodiments of the present disclosure,consideration may be made of the type of components, placement ofcomponents, corrections for polarization of transmitted waves, and otherconsiderations. For example, continuity of the core string may become achallenge that may be corrected by the addition of an internalmechanical or electronic caliper to the coring bit electronics.

FIG. 7 illustrates a flow chart of example method 700 for performingmeasurements on core sample 412 during LWC operation with coring bitelectronics (e.g., 414 of FIGS. 2-6), in accordance with someembodiments of the present disclosure. The steps of method 700 may beperformed by various computer programs, models or any combinationthereof, configured to operate a drilling tool, perform measurements,and log/analyze results. The programs and models may includeinstructions stored on a computer readable medium and operable toperform, when executed, one or more of the steps described below. Thecomputer readable media may include any system, apparatus or deviceconfigured to store and retrieve programs or instructions such as a harddisk drive, a compact disc, flash memory or any other suitable device.The programs and models may be configured to direct a processor or othersuitable unit to retrieve and execute the instructions from the computerreadable media. Collectively, the computer programs and models used tooperate a drilling tool, perform measurements, and log/analyze resultsmay be referred to as a “drilling engineering tool” or “engineeringtool.” For illustrative purposes, method 700 is described with respectto drilling tool 116 of FIG. 1; however, method 700 may be used toperform measurements, and log/analyze results using any suitabledrilling tool.

Method 700 may start and at step 706, the engineering tool may direct adrilling tool to extract a core sample from a wellbore. For example,coring bit 102 may be directed to operate and cut core sample 412 fromwellbore 106. Once core sample 412 has been extracted from wellbore 106,method 700 may continue to step 708.

At step 708, the engineering tool may direct the coring bit assembly toobtain measurements of the core sample using the coring bit electronicsand log results. For example, coring bit electronics 414 contained incoring bit assembly 126 may perform transverse measurements usingtransmitter 502 and/or receiver 504. The measurements may be transmittedto a surface control unit and logged and/or analyzed.

At step 710, the engineering tool may determine if all measurements havebeen successfully captured and logged. If more measurements arerequired, method 700 may return to step 708 to perform additionalmeasurements. If no additional measurements are required, method 700 mayproceed to step 712.

At step 712, the engineering tool may direct the drilling tool to removethe core sample. For example, core sample 412 may be removed to thesurface or core sample 412 may be deposited into a storage compartmentfor later removal. For example, drilling tool 116 may deposit coresample 412 in a storage tube (not shown).

At step 714, the engineering tool may determine if more core samples arerequired. If more core samples are required, method 700 may return tostep 706. For example, if more measurements are required, another coresample 412 may be obtained from wellbore 106. This cycle may be repeateduntil all of core samples 412 are collected, after which, at step 716drilling tool 116 may be removed from wellbore 106. Following removal ofdrilling tool 116, method 700 may end.

Modifications, additions, or omissions may be made to method 700 withoutdeparting from the scope of the present disclosure. For example, theorder of the steps may be performed in a different manner than thatdescribed and some steps may be performed at the same time.Additionally, each individual step may include additional steps withoutdeparting from the scope of the present disclosure.

Although the present disclosure and its advantages have been describedin detail, it should be understood that various changes, substitutionsand alternations can be made herein without departing from the spiritand scope of the disclosure as defined by the following claims.

1. A drilling tool, comprising: a coring bit configured to obtain a coresample from a wellbore; a coring mandrel coupled to the coring bit, thecoring mandrel including an inner gage bore; an inner barrel disposedinside the inner gage bore; an inner sleeve disposed inside the innerbarrel, the inner sleeve configured to receive the core sample; andcoring bit electronics coupled to the coring mandrel.
 2. The drillingtool of claim 1, wherein the coring bit electronics are configured tomeasure a property associated with the core sample.
 3. (canceled)
 4. Thedrilling tool of claim 1, wherein the coring bit electronics comprise areceiver and a transmitter configured to obtain a transverse measurementor a longitudinal measurement of the property of the core sample. 5.(canceled)
 6. The drilling tool of claim 1, wherein the coring bitelectronics comprise a plurality of receivers and a plurality oftransmitters configured to obtain an anisotropic measurement of theproperty of the core sample.
 7. The drilling tool of claim 1, whereinthe coring bit electronics comprise a sensor.
 8. The drilling tool ofclaim 1, further comprising a caliper disposed on the coring mandrel. 9.A drilling tool, comprising: a coring bit configured to obtain a coresample from a wellbore; a coring mandrel coupled to the coring bit, thecoring mandrel including an inner gage bore; an inner barrel disposedinside the inner gage bore; an inner sleeve disposed inside the innerbarrel, the inner sleeve configured to receive the core sample; andcoring bit electronics associated with the inner barrel.
 10. Thedrilling tool of claim 9, wherein the coring bit electronics areconfigured to measure a property associated with the core sample. 11.(canceled)
 12. The drilling tool of claim 9, wherein the coring bitelectronics comprise a receiver and a transmitter configured to obtain atransverse measurement or a longitudinal measurement of the property ofthe core sample.
 13. (canceled)
 14. The drilling tool of claim 9,wherein the coring bit electronics comprise a plurality of receivers anda plurality of transmitters configured to obtain an anisotropicmeasurement of the property of the core sample.
 15. The drilling tool ofclaim 9, wherein the coring bit electronics comprise a sensor.
 16. Thedrilling tool of claim 9, further comprising a caliper disposed on theinner barrel.
 17. The drilling tool of claim 9, wherein the coring bitelectronics are disposed on the inner barrel or on the inner sleeve. 18.(canceled)
 19. A method for performing measurements on a core sample,comprising: extracting a core sample from a wellbore with a coring bitcoupled to a coring mandrel, the coring mandrel including an innersleeve disposed in an inner barrel for receiving the core sample;measuring a property associated with the core sample using coring bitelectronics coupled to the coring mandrel; and transmitting themeasurement from the coring bit electronics to a surface.
 20. The methodof claim 19, wherein the coring bit electronics comprise a receiver anda transmitter configured to obtain a transverse measurement or alongitudinal measurement of the property of the core sample. 21.(canceled)
 22. The method of claim 19, wherein the coring bitelectronics comprise a plurality of receivers and a plurality oftransmitters configured to obtain an anisotropic measurement of theproperty of the core sample.
 23. The method of claim 19, wherein thecoring bit electronics comprise a sensor.
 24. (canceled)
 25. The methodof claim 19, further comprising a caliper disposed on the coringmandrel.
 26. A method for performing measurements on a core sample,comprising: extracting a core sample from a wellbore with a coring bitcoupled to a coring mandrel, the coring mandrel including an innersleeve disposed in an inner barrel for receiving the core sample;measuring a property associated with the core sample using coring bitelectronics associated with the inner barrel; and transmitting themeasurement from the coring bit electronics to a surface.
 27. The methodof claim 26, wherein the coring bit electronics comprise a receiver anda transmitter configured to obtain a transverse measurement or alongitudinal measurement of the property of the core sample. 28.(canceled)
 29. The method of claim 26, wherein the coring bitelectronics comprise a plurality of receivers and a plurality oftransmitters configured to obtain an anisotropic measurement of theproperty of the core sample.
 30. The method of claim 26, wherein thecoring bit electronics comprise a sensor.
 31. (canceled)
 32. The methodof claim 26, further comprising a caliper disposed on the inner barrel.33. The method of claim 26, wherein the coring bit electronics aredisposed on the inner barrel or the inner sleeve.
 34. (canceled)